EP1379488A1 - Inhibiteur d'hydrate de gaz - Google Patents

Inhibiteur d'hydrate de gaz

Info

Publication number
EP1379488A1
EP1379488A1 EP02717642A EP02717642A EP1379488A1 EP 1379488 A1 EP1379488 A1 EP 1379488A1 EP 02717642 A EP02717642 A EP 02717642A EP 02717642 A EP02717642 A EP 02717642A EP 1379488 A1 EP1379488 A1 EP 1379488A1
Authority
EP
European Patent Office
Prior art keywords
gas hydrate
hydrate inhibitor
gas
meth
vcl
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
EP02717642A
Other languages
German (de)
English (en)
Other versions
EP1379488B1 (fr
EP1379488A4 (fr
Inventor
Vu Thieu
Kirill N. Bakeev
Jenn S. Shih
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ISP Investments LLC
Original Assignee
ISP Investments LLC
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by ISP Investments LLC filed Critical ISP Investments LLC
Publication of EP1379488A1 publication Critical patent/EP1379488A1/fr
Publication of EP1379488A4 publication Critical patent/EP1379488A4/fr
Application granted granted Critical
Publication of EP1379488B1 publication Critical patent/EP1379488B1/fr
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/22—Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10S585/00—Chemistry of hydrocarbon compounds
    • Y10S585/949—Miscellaneous considerations
    • Y10S585/95—Prevention or removal of corrosion or solid deposits
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
    • Y10T137/00—Fluid handling
    • Y10T137/0318—Processes
    • Y10T137/0324—With control of flow by a condition or characteristic of a fluid
    • Y10T137/0329—Mixing of plural fluids of diverse characteristics or conditions
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
    • Y10T137/00—Fluid handling
    • Y10T137/0318—Processes
    • Y10T137/0391—Affecting flow by the addition of material or energy

Definitions

  • the invention relates to a method for preventing or retarding the formation of gas hydrates or for reducing the tendency of such hydrates to agglomerate during the transport of a fluid comprising water and a hydrocarbon through a conduit, and, more particularly, to the addition to the fluid of a gas hydrate inhibitor which is a copolymer of vinyl caprolactam and N,N-diethylaminoethyl(meth)acrylate of defined composition, which is preferably made and applied in a suitable solvent.
  • a gas hydrate inhibitor which is a copolymer of vinyl caprolactam and N,N-diethylaminoethyl(meth)acrylate of defined composition, which is preferably made and applied in a suitable solvent.
  • a useful composition for effectively preventing or retarding the formation of gas hydrates, or for reducing the tendency of gas hydrates to agglomerate, during the transport of a fluid comprising water and a hydrocarbon, through a conduit, which includes a copolymer of vinyl caprolactam (VCL) and N,N-diethylaminoethyl(meth) acrylate (DEAEMA), preferably 80-95 wt.% of VCL and 5-20 wt.% DE ⁇ AEMA.
  • VCL vinyl caprolactam
  • DEAEMA N,N-diethylaminoethyl(meth) acrylate
  • the copolymer is made and applied in a low molecular weight glycol ether, usually 2-butoxyethanol (BGE).
  • the gas hydrate inhibitor of the invention i.e. copolymer of 80-95 wt.% VCL and 5-20 wt.% DEAEMA, is present in an amount of about 30 to 50% by weight of the composition, i.e. in admixture with the solvent.
  • the product inhibition concentration in the pipeline, i.e. in the aqueous phase is about 0.1 to 3% by weight.
  • the solvent inhibition concentration accordingly, is about 0.1 to 5% by weight in the aqueous phase.
  • Suitable solvents include low molecular glycol ethers containing an alkoxy group having at least 3 carbon atoms, N-methylpyrrolidone (NMP), ethylene glycol, water and blends thereof.
  • Representative glycol ethers include 2-butoxyethanol (ethylene glycol monobutyl ether); propylene glycol butyl ether; (diethylene glycol) monobutyl ether; and 2-isopropoxy-ethanol.
  • 2-Butoxyethanol (BGE) is preferred.
  • the copolymers are made in the desired solvent and maintained therein in the composition of the invention. Less preferably, they are made in another solvent, such as isopropanol solvent, the solvent removed, and the desired glycol ether solvent added.
  • another solvent such as isopropanol solvent, the solvent removed, and the desired glycol ether solvent added.
  • the copolymer is made in BGE at about 50% solids and then ethylene glycol is added with water as solvent.
  • the gas hydrate inhibition tests were conducted in a 500 ml, 316 stainless steel autoclave vessel having a usable volume of 200 ml, equipped with a thermostated cooling jacket, sapphire window, inlet and outlet, platinum resistance thermometer (PRT) and magnetic stirring pellet.
  • the rig is rated up to 400°C and down to -25°C. Temperature and pressure are data logged, while the cell content is visually monitored by a horoscope video camera connected to a time lapsed video recorder. Hydrate formation in the rig is detected using a combination of three methods: visual detection of hydrate crystals, decrease in vessel pressure due to gas uptake and by the temperature exotherm created by heat released during hydrate formation.
  • the rigs were thoroughly cleaned after each test. Each rig was initially rinsed 3 times each with 500 ml tap water after the test fluid was removed. An air drill fitted with a 3M Scotch-Brite cylindrical scouring pad was then used to remove traces of any adsorbed chemicals therein with a small amount of water added to the rig. Each rig was then rinsed with 500 ml double distilled water 2 more times and dried. A blank solution of 200 ml double distilled water was run to confirm test reproducibility. The formation of hydrates within 4-15 minutes was taken as a standard time for a given set of testing conditions, i.e. synthetic gas, 35 bar, and 4.5°C. The cleaning procedure was repeated until a reproducible time was achieved.
  • Synthetic gas mixture of the following composition was used for hydrate testing:
  • the stirrer was started at 500 rpm and the temperature (4.5°C), pressure (75 bar) and start time (t 0 ) recorded. The run was terminated upon the formation of hydrates, usually at the moment of a pressure drop, which might or might not follow the exotherm and visual hydrates formation depending on the amount of the hydrates formed and the amplitude of the effect. The final temperature, pressure and time (t) of the hydrates formation were noted.
  • the onset of the hydrate formation time t-t 0 (mins) is indicated in the examples given below.
  • the relative efficiencies of the inhibiting polymers are thus proportional to the measured induction times.
  • the plot shows the performance, in terms of average induction times for the onset of gas hydrate formation, of P(VCL/DEAEMA) at various compositions. The test period for these trials was 24 hours (1 ,440 minutes). Upon the formation of hydrates, the run was terminated and the time of hydrate formation noted.
  • the FIGURE shows the effectiveness of gas hydrate inhibition of a copolymer of VCL and DEAEMA at a wt.% range of 80-95 wt.% VCL and 5-20 wt.% DEAEMA, preferably 85-95% VCL and 5-15% DEAEMA, as measured by the induction time, as compared to 100% VCL and 0% DEAEMA.
  • the induction time in minutes is at least 1000 to 1250, whereas lower or higher amounts of DEAEMA in the copolymer lower the induction time to only about 250 to 500 minutes.
  • An optimum performance is achieved at about 13 wt.% DEAEMA.
  • Unneutralized copolymer is preferred for successful performance; however, if desired to increase the water solubility of the copolymer in the system, it may be neutralized to a suitable pH.
  • VCL is the preferred monomer
  • similar results may be obtained with vinyl pyrrolidone, N-isopropyl(meth)acrylamide, (meth)acryloylpyrrolidine, wholly or in part, in its place; and with other comonomers such as N,N-dimethylaminoethyl methacrylate, N-(3-dimethylaminopropyl) methacrylamide (DMAPMA) wholly or in part, for DEAEMA.
  • DMAPMA N,N-dimethylaminoethyl methacrylate
  • DMAPMA N-(3-dimethylaminopropyl) methacrylamide
  • the compositions of the invention exhibit both gas hydrate and some corrosion inhibition properties, which, thereby, contributes to their commercial success.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
  • Compositions Of Macromolecular Compounds (AREA)
  • Gas Separation By Absorption (AREA)
  • Solid-Sorbent Or Filter-Aiding Compositions (AREA)
  • Silver Salt Photography Or Processing Solution Therefor (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
EP20020717642 2001-03-20 2002-03-14 Inhibiteur d'hydrate de gaz Expired - Lifetime EP1379488B1 (fr)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US812504 1991-12-20
US09/812,504 US6359047B1 (en) 2001-03-20 2001-03-20 Gas hydrate inhibitor
PCT/US2002/007959 WO2002074722A1 (fr) 2001-03-20 2002-03-14 Inhibiteur d'hydrate de gaz

Publications (3)

Publication Number Publication Date
EP1379488A1 true EP1379488A1 (fr) 2004-01-14
EP1379488A4 EP1379488A4 (fr) 2004-10-20
EP1379488B1 EP1379488B1 (fr) 2011-08-24

Family

ID=25209775

Family Applications (1)

Application Number Title Priority Date Filing Date
EP20020717642 Expired - Lifetime EP1379488B1 (fr) 2001-03-20 2002-03-14 Inhibiteur d'hydrate de gaz

Country Status (9)

Country Link
US (1) US6359047B1 (fr)
EP (1) EP1379488B1 (fr)
AT (1) ATE521585T1 (fr)
BR (1) BR0208317A (fr)
CA (1) CA2442783A1 (fr)
MX (1) MXPA03008523A (fr)
NO (1) NO334634B1 (fr)
OA (1) OA12458A (fr)
WO (1) WO2002074722A1 (fr)

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US7164051B2 (en) * 2002-09-03 2007-01-16 Baker Hughes Incorporated Gas hydrate inhibitors
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US7741251B2 (en) * 2002-09-06 2010-06-22 Halliburton Energy Services, Inc. Compositions and methods of stabilizing subterranean formations containing reactive shales
US7220708B2 (en) * 2003-02-27 2007-05-22 Halliburton Energy Services, Inc. Drilling fluid component
US8181703B2 (en) 2003-05-16 2012-05-22 Halliburton Energy Services, Inc. Method useful for controlling fluid loss in subterranean formations
US8251141B2 (en) * 2003-05-16 2012-08-28 Halliburton Energy Services, Inc. Methods useful for controlling fluid loss during sand control operations
US7182136B2 (en) * 2003-07-02 2007-02-27 Halliburton Energy Services, Inc. Methods of reducing water permeability for acidizing a subterranean formation
US8631869B2 (en) * 2003-05-16 2014-01-21 Leopoldo Sierra Methods useful for controlling fluid loss in subterranean treatments
US7117942B2 (en) * 2004-06-29 2006-10-10 Halliburton Energy Services, Inc. Methods useful for controlling fluid loss during sand control operations
US7759292B2 (en) * 2003-05-16 2010-07-20 Halliburton Energy Services, Inc. Methods and compositions for reducing the production of water and stimulating hydrocarbon production from a subterranean formation
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US8962535B2 (en) 2003-05-16 2015-02-24 Halliburton Energy Services, Inc. Methods of diverting chelating agents in subterranean treatments
US8278250B2 (en) * 2003-05-16 2012-10-02 Halliburton Energy Services, Inc. Methods useful for diverting aqueous fluids in subterranean operations
JP4230881B2 (ja) * 2003-10-23 2009-02-25 富士通マイクロエレクトロニクス株式会社 半導体集積回路、及びレベル変換回路
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US20080110624A1 (en) * 2005-07-15 2008-05-15 Halliburton Energy Services, Inc. Methods for controlling water and particulate production in subterranean wells
US7441598B2 (en) * 2005-11-22 2008-10-28 Halliburton Energy Services, Inc. Methods of stabilizing unconsolidated subterranean formations
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US7687438B2 (en) * 2006-09-20 2010-03-30 Halliburton Energy Services, Inc. Drill-in fluids and associated methods
US7678742B2 (en) * 2006-09-20 2010-03-16 Halliburton Energy Services, Inc. Drill-in fluids and associated methods
US7678743B2 (en) * 2006-09-20 2010-03-16 Halliburton Energy Services, Inc. Drill-in fluids and associated methods
US7730950B2 (en) 2007-01-19 2010-06-08 Halliburton Energy Services, Inc. Methods for treating intervals of a subterranean formation having variable permeability
US7934557B2 (en) 2007-02-15 2011-05-03 Halliburton Energy Services, Inc. Methods of completing wells for controlling water and particulate production
US8430169B2 (en) * 2007-09-25 2013-04-30 Exxonmobil Upstream Research Company Method for managing hydrates in subsea production line
US7552771B2 (en) * 2007-11-14 2009-06-30 Halliburton Energy Services, Inc. Methods to enhance gas production following a relative-permeability-modifier treatment
US20090253594A1 (en) * 2008-04-04 2009-10-08 Halliburton Energy Services, Inc. Methods for placement of sealant in subterranean intervals
EP2346909B1 (fr) * 2008-11-13 2018-05-16 Isp Investments Inc. Polymères dérivés du n-vinylformamide, de vinyle amides ou d'acrylamides et de solvant de réaction, et leurs utilisations
US7998910B2 (en) 2009-02-24 2011-08-16 Halliburton Energy Services, Inc. Treatment fluids comprising relative permeability modifiers and methods of use
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US20120247972A1 (en) * 2011-03-31 2012-10-04 Baker Hughes Incorporated Process for reducing the concentration of hydrate inhibitors in water used for oil and gas production
US9145465B2 (en) 2011-10-20 2015-09-29 Baker Hughes Incorporated Low dosage kinetic hydrate inhibitors for natural gas production systems
KR101239201B1 (ko) 2011-11-03 2013-03-05 한국에너지기술연구원 가스 하이드레이트 생성 억제용 조성물 및 가스 하이드레이트 생성 억제 방법
US9790104B2 (en) 2012-02-17 2017-10-17 Hydrafact Limited Water treatment
WO2015138048A1 (fr) 2014-03-12 2015-09-17 Exxonmobil Upstream Research Company Système et procédé d'inhibition de croissance de film d'hydrate sur parois tubulaires
WO2016064480A1 (fr) 2014-10-22 2016-04-28 Exxonmobil Upstream Research Company Entraînement de particules d'hydrates dans un flux de gaz
AU2016322891B2 (en) 2015-09-18 2020-02-27 Indorama Ventures Oxides Llc Improved poly(vinyl caprolactam) kinetic gas hydrate inhibitor and method for preparing the same
CN115197367A (zh) * 2022-07-20 2022-10-18 西南石油大学 基于乙烯基吡咯烷酮的三元水合物抑制剂及制备方法
CN115141312A (zh) * 2022-07-20 2022-10-04 西南石油大学 基于乙烯基吡咯烷酮的水合物抑制剂及制备方法
CN115260391A (zh) * 2022-08-09 2022-11-01 西南石油大学 基于乙烯基己内酰胺的水合物抑制剂及制备方法
CN115260392A (zh) * 2022-08-09 2022-11-01 西南石油大学 基于乙烯基己内酰胺的三元水合物抑制剂及制备方法

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Also Published As

Publication number Publication date
EP1379488B1 (fr) 2011-08-24
MXPA03008523A (es) 2003-12-08
NO20034181L (no) 2003-09-19
NO334634B1 (no) 2014-05-05
EP1379488A4 (fr) 2004-10-20
CA2442783A1 (fr) 2002-09-26
OA12458A (en) 2006-05-24
WO2002074722A1 (fr) 2002-09-26
US6359047B1 (en) 2002-03-19
NO20034181D0 (no) 2003-09-19
ATE521585T1 (de) 2011-09-15
BR0208317A (pt) 2004-03-23

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